Pump with valve with moveable valve member

ABSTRACT

A pump assembly includes a power end, a fluid end, and a valve assembly located in the fluid end. The valve assembly includes a valve seat and a valve member including a valve body connected to a valve stem and reciprocatable during operation to engage the valve seat. The valve member is moveable during operation such that the orientation of the valve body relative to the valve seat is adjustable.

BACKGROUND

High-pressure pumps having reciprocating elements such as plungers orpistons are commonly employed in oil and gas production fields foroperations such as drilling and well servicing. For instance, one ormore reciprocating pumps may be employed to pump fluids into a wellborein conjunction with activities including fracturing, acidizing,remediation, cementing, and other stimulation or servicing activities.Due to the harsh conditions associated with such activities, manyconsiderations are generally considered when designing a pump for use inoil and gas operations. One design consideration may concern lifetimeand reliability of pump fluid end components, as reciprocating pumpsused in wellbore operations, for example, often encounter high cyclicalpressures and various other conditions that can render pump componentssusceptible to wear and result in a need for servicing and maintenanceof the pump. Another design consideration is the type of fluids beingpumped. Some fluids may be slurries that include a solid component. Thesolid component in the fluid may become an obstruction in the operationof some pump components. For example, valve assemblies can include valveguides that position a valve body relative to a valve seat. Valve guidesin slurry pumps require increased clearance or “slop” between the valvestem and the valve guide to account for high proppant concentrationswhich can bridge and bind in tight clearance areas. Typical frac pumpsutilize valving in the vertical or near vertical position in which thishigh clearance or sloppy fit does not interfere with valve performance.However, concentric style fluid ends can utilize valving a horizontalorientation that proves troublesome in operation by biasing the requiredvalve guide clearance all to one side, such that the valve stem is offcenter, leading to uneven valve, seat, and guide wear.

Accordingly, it is desirable to provide a pump with a fluid end thatenhances a life of components therein, such as a valve assembly.

BRIEF DESCRIPTION OF THE DRAWINGS

Embodiments of the pump with valve with flexible connection aredescribed with reference to the following figures. The same orsequentially similar numbers are used throughout the figures toreference like features and components. The features depicted in thefigures are not necessarily shown to scale. Certain features of theembodiments may be shown exaggerated in scale or in somewhat schematicform, and some details of elements may not be shown in the interest ofclarity and conciseness.

FIG. 1 is an elevation view of a reciprocating pump, according to one ormore embodiments of this disclosure.

FIG. 2A is a cut-away illustration of an exemplary reciprocating pumpcomprising a concentric bore pump fluid end, according to one or moreembodiments of the present disclosure.

FIG. 2B is a cut-away illustration of an exemplary reciprocating pumpcomprising a cross-bore pump fluid end, according to one or moreembodiments of the present disclosure.

FIG. 3 is cut-away illustration of a pump power end of a pump, accordingto one or more embodiments of the present disclosure.

FIG. 4 is a schematic of a horizontal valve assembly, according to oneor more embodiments of the present disclosure.

FIGS. 5A and 5B are schematics of a valve assembly, according toembodiments of the present disclosure, in a closed configuration andwhere an obstruction is in the valve assembly.

FIG. 6 is a schematic of another valve assembly of this disclosure.

FIG. 7 is a schematic representation of an embodiment of a wellboreservicing system, according to embodiments of this disclosure.

DETAILED DESCRIPTION

It should be understood at the outset that although an illustrativeimplementation of one or more embodiments are provided below, thedisclosed systems and/or methods may be implemented using any number oftechniques, whether currently known or in existence. The disclosureshould in no way be limited to the illustrative implementations,drawings, and techniques illustrated below, including the exemplarydesigns and implementations illustrated and described herein, but may bemodified within the scope of the appended claims along with their fullscope of equivalents.

Disclosed herein is a reciprocating apparatus for pumping pressurizedfluid that is part of a pump assembly. In embodiments, the reciprocatingapparatus comprises a pump fluid end containing a valve assembly that isoperable with a power end of the pump assembly. The valve assembly ofthis disclosure comprises a horizontal valve assembly that includes avalve seat and a valve body contact surface. The valve assembly alsocomprises a valve guide, and a valve member that includes a valve bodyconnected to a valve stem. The valve stem translates in the valve guideto move the valve member between a closed configuration, where the valvebody contacts the valve seat in a sealing arrangement to prevent fluidflow through the valve assembly, and an open configuration, where thevalve body is separated from the valve seat to allow fluid flow throughthe valve assembly. The valve member is moveable during operation suchthat the orientation of the valve body relative to the valve seat isadjustable. The valve member is movable by either the valve bodypivoting relative to the valve stem or by bending the valve stem.

In embodiments, the reciprocating apparatus is a high-pressure pumpconfigured to operate at a pressure greater than or equal to about 3,000psi (21 MPa) and/or in a well servicing operation and environment. Asdetailed further herein below, utilization of a valve assembly of thisdisclosure as a suction valve assembly and/or a discharge valve assemblyof a pump can increase a life and/or reduce a cost relative to aconventional valve assembly by accommodating obstructions that may lodgebetween the valve body and the valve seat in the closed configuration,thus reducing maintenance cost and downtime for maintenance of the pump.

A reciprocating apparatus of this disclosure may comprise any suitablepump operable to pump fluid, including slurries. Non-limiting examplesof suitable pumps include, but are not limited to, piston pumps, plungerpumps, and the like. In embodiments, the pump is a rotary- orreciprocating-type pump such as a positive displacement pump operable todisplace pressurized fluid. The pump comprises a pump power end, a pumpfluid end, and an integration section whereby a reciprocating element(e.g., a plunger) can be mechanically connected with the pump power endsuch that the reciprocating element can be reciprocated within areciprocating element bore of the pump fluid end.

FIG. 1 is an elevation view (e.g., side view) of a pump 10 (e.g., areciprocating pump) according to an exemplary embodiment, thereciprocating pump comprises a pump power end 12, a pump fluid end 22,and an integration section 11. As illustrated in FIG. 1 , pump fluid endhas a front S1 opposite a back S2 along a first or x-axis, a top S3opposite a bottom S4 along a second or y-axis, wherein the y-axis is inthe same plane as and perpendicular to the x-axis, and a left side and aright side along a z-axis, wherein the z-axis is along a planeperpendicular to the plane of the x-axis and the y-axis. Accordingly,toward the top of pump fluid end 22 (and pump 10) is along the y-axistoward top S3, toward the bottom of pump fluid end 22 (and pump 10) isalong the y-axis toward bottom S4, toward the front of pump fluid end 22(and pump 10) is along the x-axis toward front S1, and toward the backof pump fluid end 22 (and pump 10) is along the x-axis away from frontS1.

The pump fluid end 22 is integrated with the pump power end 12 via theintegration section 11, such that pump power end 12 is operable toreciprocate the reciprocating element 18 within a reciprocating elementbore 24 (FIGS. 2A and 2B) of the pump fluid end 22. The reciprocatingelement bore 24 is at least partially defined by a cylinder wall 26. Asdescribed further herein below with reference to FIGS. 2A and 2B, pumpfluid end 22 can be a multi-bore pump fluid end (also referred to hereinas a cross-bore pump fluid end) 22 or, alternatively, an in-line or“concentric” bore pump fluid end. As utilized herein, multi-bore pumpfluid ends can comprise “T-bore” pump fluid ends, “X-bore” (e.g., crossshaped bore) pump fluid ends, or “Y-bore” pump fluid ends.

FIG. 2A is a schematic showing a concentric bore pump fluid end 22engaged with a reciprocating element 18. FIG. 2B is a schematic showinga T-bore pump fluid end 22 engaged with a reciprocating element 18. In aT-bore pump fluid end 22, reciprocating element bore 24 and T-bore 25are perpendicular, making the shape of a “T”. As discussed furtherbelow, the pump 10 includes at least one fluid inlet 38 for receivingfluid from a fluid source, e.g., a suction line, suction header, storageor mix tank, blender, discharge from a boost pump such as a centrifugalpump, etc. The pump 10 also includes at least one discharge outlet 54for discharging fluid to a discharge source, e.g., a flowmeter, pressuremonitoring and control system, distribution header, discharge line,wellhead, discharge manifold pipe, and the like.

The pump 10 may comprise any suitable pump power end 12 for enabling thepump 10 to perform pumping operations (e.g., pumping a wellboreservicing fluid downhole). Similarly, the pump 10 may include anysuitable housing 14 for containing and/or supporting the pump power end12 and components thereof. The housing 14 may comprise variouscombinations of inlets, outlets, channels, and the like for circulatingand/or transferring fluid. Additionally, the housing 14 may includeconnections to other components and/or systems, such as, but not limitedto, pipes, tanks, drive mechanisms, etc. Furthermore, the housing 14 maybe configured with cover plates or entryways for permitting access tothe pump power end 12 and/or other pump components. As such, the pump 10may be inspected to determine whether parts need to be repaired orreplaced. The pump power end may also be hydraulically driven, whetherit is a non-intensifying or an intensifying system.

The pump 10 can be an oilfield services pump configured to pump awellbore servicing fluid. Examples of wellbore servicing fluids suitableinclude, but are not limited to, cementitious fluids (e.g., cementslurries), drilling fluids or muds, spacer fluids, fracturing fluids orcompletion fluids, and gravel pack fluids, remedial fluids, perforatingfluids, sealants, drilling fluids, completion fluids, diverter fluids,gelation fluids, polymeric fluids, aqueous fluids, oleaginous fluids,etc. The pump 10 can be used in oilfield and/or well servicingoperations which include, but are not limited to, drilling operations,fracturing operations, perforating operations, fluid loss operations,primary cementing operations, secondary or remedial cementingoperations, or any combination of operations thereof.

Those versed in the art will understand that the pump power end 12 mayinclude various components commonly employed in pumps. Pump power end 12can be any suitable pump known in the art and with the help of thisdisclosure to be operable to reciprocate reciprocating element 18 inreciprocating element bore 24. For example, without limitation, pumppower end 12 can be operable via and comprise a crank and slidermechanism, a powered hydraulic/pneumatic/steam cylinder mechanism orvarious electric, mechanical, or electro-mechanical drives.

FIG. 3 provides a cutaway illustration of an exemplary pump 10 of thisdisclosure, showing an exemplary pump power end 12, integrated viaintegration section 11 with a pump fluid end 22, wherein the pump powerend 12 is operable to reciprocate the reciprocating element 18 within areciprocating element bore 24 of the pump fluid end 22. Briefly, forexample, the pump power end 12 may include a rotatable crankshaft 16attached to at least one reciprocating element 18 (e.g., a plunger orpiston) by way of a crank arm/connecting rod 21. Additionally, an engine(e.g., a diesel engine), motor, or other suitable power source may beoperatively connected to the crankshaft 16 (e.g., through a transmissionand drive shaft) and operable to actuate rotation thereof. In operation,rotation of the crankshaft 16 induces translational movement of thecrank arm/connecting rod 20, thereby causing the reciprocating element18 to extend and retract along a flow path, which may generally bedefined by a central axis 17 within a reciprocating element bore 24(sometimes referred to herein for brevity as a “reciprocating elementbore 24” or simply a “bore 24”, and not wishing to be limited to aparticular reciprocating element 18). Pump 10 of FIG. 1 is typicallymounted on a movable structure such as a semi-tractor trailer or skid,and the moveable structure may contain additional components, such as amotor or engine (e.g., a diesel engine), that provides power (e.g.,mechanical motion) to the pump power end 12 (e.g., a crankcasecomprising crankshaft 16 and related connecting rods 20).

As noted herein above, the pump 10 comprises a pump fluid end 22attached to the pump power end 12. Various embodiments of the pump fluidend 22 are described in detail below in connection with other drawings,for example FIGS. 2A and 2B. Generally, the pump fluid end 22 comprisesat least one fluid inlet 38 for receiving fluid, and at least onedischarge outlet 54 through which fluid flows out of the dischargechamber 53. The pump fluid end 22 also comprises at least one valveassembly for controlling the receipt and output of fluid. For example,the pump fluid end 22 can comprise a suction valve assembly 56 and adischarge valve assembly 72. The pump fluid end 22 may include anysuitable component(s) and/or structure(s) for containing and/orsupporting the reciprocating element 18 and providing a cylinder wall 26at least partially defining a reciprocating element bore 24 along whichthe pump power end can reciprocate the reciprocating element duringoperation of the pump.

The pump fluid end 22 may comprise a cylinder wall 26 at least partiallydefining a bore 24 through which the reciprocating element 18 may extendand retract. Additionally, the bore 24 may be in fluid communicationwith a discharge chamber 53 formed within the pump fluid end 22. Such adischarge chamber 53, for example, may be configured as a pressurizeddischarge chamber 53 having a discharge outlet 54 through which fluid isdischarged by the reciprocating element 18. Thus, the reciprocatingelement 18 may be movably disposed within the reciprocating element bore24, which may provide a fluid flow path into and/or out of the pumpchamber. During operation of the pump 10, the reciprocating element 18may be configured to reciprocate along a path (e.g., along central axis17 within bore 24 and/or pump chamber 28, which corresponds toreciprocal movement parallel to the x-axis of FIG. 1 ) to transfer asupply of fluid to the pump chamber 28 and/or discharge fluid from thepump chamber 28.

In operation, the reciprocating element 18 extends and retracts along aflow path to alternate between providing forward strokes (also referredto as discharge strokes and correlating to movement in a positivedirection parallel to the x-axis of FIG. 1 , indicated by arrow 117) andreturn strokes (also referred to as suction strokes and correlating tomovement in a negative direction parallel to the x-axis of FIG. 1 ,indicated by arrow 116), respectively. During a forward stroke, thereciprocating element 18 extends away from the pump power end 12 andtoward the pump fluid end 22. Before the forward stoke begins, thereciprocating element 18 is in a fully retracted position (also referredto as bottom dead center (BDC) with reference to the crankshaft 16), inwhich case the suction valve assembly 56 can be in a closedconfiguration having allowed fluid to flow into the (e.g., highpressure) pump chamber 28. (As utilized here, “high pressure” indicatespossible subjection to high pressure during discharge.) When dischargevalve assembly 72 is in a closed configuration (e.g., under theinfluence of a closing mechanism, such as a spring), the high pressurein a discharge pipe or manifold containing discharge outlet 54 preventsfluid flow into discharge chamber 53 and causes pressure in the pumpchamber 28 to accumulate upon stroking of the reciprocating element 18.When the reciprocating element 18 begins the forward stroke, thepressure builds inside the pump chamber 28 and acts as an opening forcethat results in positioning of the discharge valve assembly 72 in anopen configuration, while a closing force (e.g., via a closingmechanism, such as a spring and/or pressure increase inside pump chamber28) urges the suction valve assembly 56 into a closed configuration.When utilized in connection with a valve assembly, “open” and “closed”refer, respectively, to a configuration in which fluid can flow throughthe valve assembly (e.g., can pass between a valve body (e.g., a movablepoppet) and a valve seat thereof) and a configuration in which fluidcannot flow through the valve assembly (e.g., cannot pass between avalve body (e.g., a movable poppet) and a valve seat thereof). As thereciprocating element 18 extends forward, fluid within the pump chamber28 is discharged through the discharge outlet 54.

During a return stroke, the reciprocating element 18 reciprocates orretracts away from the pump fluid end 22 and towards the pump power end12 of the pump 10. Before the return stroke begins, the reciprocatingelement 18 is in a fully extended position (also referred to as top deadcenter (TDC) with reference to the crankshaft 16), in which case thedischarge valve assembly 72 can be in a closed configuration havingallowed fluid to flow out of the pump chamber 28 and the suction valveassembly 56 is in a closed configuration. When the reciprocating element18 begins and retracts towards the pump power end 12, the dischargevalve assembly 72 assumes a closed configuration, while the suctionvalve assembly 56 opens. As the reciprocating element 18 moves away fromthe discharge valve 72 during a return stroke, fluid flows through thesuction valve assembly 56 and into the pump chamber 28.

With reference to the embodiment of FIG. 2A, which is a schematicshowing a concentric pump fluid end 22 engaged with a reciprocatingelement 18, concentric bore pump fluid end 22 comprises a concentricbore fluid end body 8, a concentric pump chamber 28, a suction valveassembly 56, and a discharge valve assembly 72. In this concentric boreconfiguration of FIG. 2A, suction valve assembly 56 and discharge valveassembly 72 are positioned in-line (also referred to as coaxial) withreciprocating element bore 24, i.e., central axis 17 of reciprocatingelement bore 24 is also the central axis of suction pump assembly 56 anddischarge valve assembly 72).

With reference to the embodiment of FIG. 2B, which is a schematicshowing a T-bore pump fluid end 22 engaged with a reciprocating element18, T-bore pump fluid end 22 comprises a T-bore fluid end body 8, aT-shaped pump chamber 28, a suction valve assembly 56, and a dischargevalve assembly 72. In this T-bore configuration of FIG. 2B, suctionvalve assembly 56 is coupled with front end 60 of reciprocating element18 and discharge valve assembly 72 is positioned in bore 25 that makes atee with reciprocating element bore 24, i.e., central axis 17 ofreciprocating element bore 24 is also the central axis of suction pumpassembly 56 and perpendicular to a central axis 27 of discharge valveassembly 72).

Suction valve assembly 56 and discharge valve assembly 72 are operableto direct fluid flow within the pump 10. In pump fluid end 22 designs ofthis disclosure, fluid flows within a hollow reciprocating element(e.g., a hollow plunger) 18 via fluid inlet 38 located toward tail end62 of reciprocating element 18. The reciprocating element bore 24 ofsuch a fluid end design can be defined by a high-pressure cylinder orcylinder wall 26 providing a high-pressure chamber. (As utilized here,“high-pressure” indicates possible subjection to high pressure duringdischarge.) When reciprocating element 18 retracts, or moves alongcentral axis 17 in a direction away from the pump chamber 28 and pumpfluid end 22 and toward pump power end 12 (as indicated by arrow 116), asuction valve of the suction valve assembly 56 opens (e.g., either undernatural flow and/or other biasing means), and a discharge valve ofdischarge valve assembly 72 will be closed, whereby fluid enters pumpchamber 28 via a fluid inlet 38. For a pump fluid end 22 design of thisdisclosure, the fluid inlet 38 is configured to introduce fluid intopump chamber 28 via a reciprocating element 18 that is hollow. When thereciprocating element 18 reverses direction, due to the action of thepump power end 12, the reciprocating element 18 reverses direction alongcentral axis 17, now moving in a direction toward the pump chamber 28and pump fluid end 22 and away from pump power end 12 (as indicated byarrow 117), and the discharge valve of discharge valve assembly 72 isopen and the suction valve of suction valve assembly 56 is closed (e.g.,again either due to fluid flow and/or other biasing means of valvecontrol), such that fluid is pumped out of pump chamber 28 via dischargechamber 53 and discharge outlet 54.

A pump 10 of this disclosure can comprise one or more access ports. Withreference to the concentric fluid end body 8 embodiment of FIG. 2A, afront access port 30A can be located on a front S1 of the pump fluid end22 opposite a back S2 of the pump fluid end 22, wherein the back S2 ofthe pump fluid end is proximal the pump power end 12, upon integrationtherewith via integration section 11. With reference to the T-bore fluidend body 8 embodiment of FIG. 2B, a front access port 30A can be locatedon a front S1 of the pump fluid end 22 opposite a back S2 of the pumpfluid end 22, wherein the back S2 of the pump fluid end is proximal thepump power end 12, upon integration therewith via integration section11, and a top access port 30B can be located on a top S3 of the pumpfluid end 22 opposite a bottom S4 of pump fluid end 22. Locationsdescribed as front S1, back S2, top S3, and bottom S4 are furtherdescribed with reference to the x-y-z coordinate system shown in FIG. 1and further can be relative to a surface (e.g., a trailer bed, theground, a platform, etc.) upon which the pump 10 is located, a bottom S4of the pump fluid end being proximal the surface (e.g., trailer bed)upon which the pump 10 is located. Generally, due to size andpositioning of pump 10, the front S1 and top S3 of the pump fluid end 22are more easily accessible than a back S2 or bottom S4 thereof. In asimilar manner, a front of pump 10 is distal the pump power end 12 and aback of the pump 10 is distal the pump fluid end 22. The integrationsection 11 can be positioned in a space between the pump fluid end 22and the pump power end 12, and can be safeguarded (e.g., from personnel)via a cover 15.

A pump 10 of this disclosure can be a multiplex pump comprising aplurality of reciprocating assemblies (e.g., reciprocating elements 18,and a corresponding plurality of reciprocating element bores 24, suctionvalve assemblies 56, and discharge valve assemblies 72). The pluralitycan comprise any number such as, for example, 2, 3, 4, 5, 6, 7, or more.For example, in embodiments, pump 10 is a triplex pump, wherein theplurality comprises three. In alternative embodiments, pump 10 comprisesa quintuplex pump, wherein the plurality comprises five.

In embodiments, a pump fluid end 22 and pump 10 of this disclosurecomprise at least one access port. In embodiments, the at least oneaccess port is located on a side of the discharge valve assembly 72opposite the suction valve assembly 56. For example, in the concentricbore pump fluid end 22 embodiment of FIG. 2A, front access port 30A islocated on a side (e.g., front side) of discharge valve assembly 72opposite suction valve assembly 56. In the T-bore pump fluid end 22embodiment of FIG. 2B, front access port 30A is located on top S3 ofpump fluid end 22.

In embodiments, one or more seals 29 (e.g., “o-ring” seals, packingseals, or the like), also referred to herein as ‘primary’ reciprocatingelement packing 29 (or simply “packing 29”) may be arranged around thereciprocating element 18 to provide sealing between the outer walls ofthe reciprocating element 18 and the inner walls 26 defining at least aportion of the reciprocating element bore 24. In some concentric borefluid end designs, a second set of seals (also referred to herein as‘secondary’ reciprocating element packing; not shown in the Figures) maybe fixedly arranged around the reciprocating element 18 to providesealing between the outer walls of the reciprocating element 18 and theinner walls of a low-pressure cylinder that defines the low pressurechamber described hereinabove (e.g., wherein the secondary packing isfarther back along the x-axis and delineates a back end of the lowpressure chamber that extends from the primary packing 29 to thesecondary packing). Skilled artisans will recognize that the seals maycomprise any suitable type of seals, and the selection of seals maydepend on various factors e.g., fluid, temperature, pressure, etc.

While the foregoing discussion focused on a pump fluid end 22 comprisinga single reciprocating element 18 disposed in a single reciprocatingelement bore 24, it is to be understood that the pump fluid end 22 mayinclude any suitable number of reciprocating elements. As discussedfurther below, for example, the pump 10 may comprise a plurality ofreciprocating elements 18 and associated reciprocating element bores 24arranged in parallel and spaced apart along the z-axis of FIG. 1 (oranother arrangement such as a V block or radial arrangement). In such amulti-bore pump, each reciprocating element bore may be associated witha respective reciprocating element and crank arm, and a single commoncrankshaft may drive each of the plurality of reciprocating elements andcrank arms. Alternatively, a multi-bore pump may include multiplecrankshafts, such that each crankshaft may drive a correspondingreciprocating element. Furthermore, the pump 10 may be implemented asany suitable type of multi-bore pump. In a non-limiting example, thepump 10 may comprise a triplex pump having three reciprocating elements18 (e.g., plungers or pistons) and associated reciprocating elementbores 24, discharge valve assemblies 72 and suction valve assemblies 56,or a quintuplex pump having five reciprocating elements 18 and fiveassociated reciprocating element bores 24, discharge valve assemblies 72and suction valve assemblies 56.

Reciprocating element bore 24 can have an inner diameter slightlygreater than the outer diameter of the reciprocating element 18, suchthat the reciprocating element 18 may sufficiently reciprocate withinreciprocating element bore 24 (optionally, within a sleeve, as describedhereinbelow). In embodiments, the fluid end body 8 of pump fluid end 22has a pressure rating ranging from about 100 psi (0.7 MPa) to about 3000psi (21 MPa), or from about 2000 psi (14 MPa) to about 10,000 psi (69MPa), from about 5000 psi (34 MPa) to about 30,000 psi (207 MPa), orfrom about 3000 psi (21 MPa) to about 50,000 psi (345 MPa) or greater.The fluid end body 8 of pump fluid end 22 may be cast, forged, machined,printed or formed from any suitable materials, e.g., steel, metalalloys, or the like. Those versed in the art will recognize that thetype and condition of material(s) suitable for the fluid end body 8 maybe selected based on various factors. In a wellbore servicing operation,for example, the selection of a material may depend on flow rates,pressure rates, wellbore service fluid types (e.g., particulate typeand/or concentration present in particle laden fluids such as fracturingfluids or drilling fluids, or fluids comprising cryogenic/foams), etc.Moreover, the fluid end body 8 (e.g., cylinder wall 26 defining at leasta portion of reciprocating element bore 24 and/or pump chamber 28) mayinclude protective coatings for preventing and/or resisting abrasion,erosion, and/or corrosion.

In embodiments, the cylindrical shape (e.g., providing cylindricalwall(s) 26) of the fluid end body 8 may be pre-stressed in an initialcompression. Moreover, a high-pressure cylinder(s) providing thecylindrical shape (e.g., providing cylindrical wall(s) 26) may compriseone or more sleeves (e.g., heat-shrinkable sleeves). Additionally, oralternatively, the high-pressure cylinder(s) may comprise one or morecomposite overwraps and/or concentric sleeves (“over-sleeves”), suchthat an outer wrap/sleeve pre-loads an inner wrap/sleeve. The overwrapsand/or over-sleeves may be non-metallic (e.g., fiber windings) and/orconstructed from relatively lightweight materials. Overwraps and/orover-sleeves may be added to increase fatigue strength and overallreinforcement of the components.

The cylinders and cylindrical-shaped components (e.g., providingcylindrical wall 26) associated with the pump fluid end body 8 of pumpfluid end 22 may be held in place within the pump 10 using anyappropriate technique. For example, components may be assembled andconnected, e.g., bolted, welded, etc. Additionally, or alternatively,cylinders may be press-fit (e.g., interference fit) into openingsmachined or cast into the pump fluid end 22 or other suitable portion ofthe pump 10. Such openings may be configured to accept and rigidly holdcylinders (e.g., having cylinder wall(s) 26 at least partially definingreciprocating element bore 24) in place to facilitate interaction of thereciprocating element 18 and other components associated with the pump10.

In embodiments, the reciprocating element 18 comprises a plunger or apiston. While the reciprocating element 18 may be described herein withrespect to embodiments comprising a plunger, it is to be understood thatthe reciprocating element 18 may comprise any suitable component fordisplacing fluid. In a non-limiting example, the reciprocating element18 may be a piston. As those versed in the art will readily appreciate,a piston-type pump generally employs sealing elements (e.g., rings,packing, etc.) attached to the piston and movable therewith. Incontrast, a plunger-type pump generally employs fixed or static seals(e.g., primary seal or packing 29) through which the plunger movesduring each stroke (e.g., suction stroke or discharge stroke).

As skilled artisans will understand, the reciprocating element 18 mayinclude any suitable size and/or shape for extending and retractingalong a flow path within the pump fluid end 22. For instance,reciprocating element 18 may comprise a generally cylindrical shape, andmay be sized such that the reciprocating element 18 can sufficientlyslide against or otherwise interact with the inner cylinder wall 26. Inembodiments, one or more additional components or mechanical linkages 48(FIG. 3 ; e.g., clamps, adapters, extensions, etc.) may be used tocouple the reciprocating element 18 to the pump power end 12 (e.g., to apushrod 9).

In some embodiments (e.g., T-bore pump fluid end 22 embodiments such asFIG. 2B), the reciprocating element 18 may be substantially solid and/orimpermeable (e.g., not hollow). In some embodiments, reciprocatingelement 18 employed in a concentric bore pump fluid end 22 embodiment(such as depicted in FIG. 2A) or a cross-bore pump fluid end 22 (such asdepicted in FIG. 2B) comprises a peripheral wall defining a hollow body.Additionally (e.g., concentric bore pump fluid end 22 embodiments suchas FIG. 2A), a portion of the peripheral wall of reciprocating element18 may be generally permeable or may include an input through whichfluid may enter the hollow body and an output through which fluid mayexit the hollow body. Furthermore, while the reciprocating element 18may, in embodiments, define a substantially hollow interior and includea ported body, a base of the reciprocating element 18 proximal the pumppower end, when assembled, may be substantially solid and/or impermeable(e.g., a plunger having both a hollow portion and a solid portion).

The reciprocating element 18 comprises a front or free end 60. Inembodiments comprising concentric bore pump fluid end designs 22 such asshown in FIG. 2A, the reciprocating element 18 can contain or at leastpartially contain the suction valve assembly 56. In embodiments, thesuction valve assembly 56 is at least partially disposed within thereciprocating element 18 at or proximate to the front end 60 thereof. Atan opposite or tail end 62 (also referred to as back or tail end 62) ofthe reciprocating element 18, the reciprocating element 18 may include abase coupled to the pump power end 12 of the pump 10 (e.g., via crankarm 20). In embodiments, the tail end 62 of the reciprocating element 18is coupled to the pump power end 12 outside of pump fluid end 22, e.g.,within integration section 11.

As noted above, pump fluid end 22 contains a suction valve assembly 56.Suction valve assembly 56 may alternately open or close to permit orprevent fluid flow. Skilled artisans will understand that the suctionvalve assembly 56 may be of any suitable type or configuration (e.g.,gravity- or spring-biased, flow activated, etc.). Those versed in theart will understand that the suction valve assembly 56 may be disposedwithin the pump fluid end 22 at any suitable location therein. Forinstance, the suction valve assembly 56 may be disposed withinreciprocating element bore 24 and at least partially withinreciprocating element 18 in concentric bore pump fluid end 22 designssuch as FIG. 2A or T-bore pump fluid end 22 designs such as FIG. 2B,such that a suction valve body of the suction valve assembly 56 movesaway from a suction valve seat within the a suction valve seat housingof reciprocating element 18 when the suction valve assembly 56 isopening and toward the suction valve seat when the suction valveassembly 56 is closing.

Pump 10 comprises a discharge valve assembly 72 for controlling theoutput of fluid through discharge chamber 53 and discharge outlet 54.Analogous to the suction valve assembly 56, the discharge valve assembly72 may alternately open or close to permit or prevent fluid flow. Thoseversed in the art will understand that the discharge valve assembly 72may be disposed within the pump chamber at any suitable locationtherein. For instance, the discharge valve assembly 72 may be disposedproximal the front S1 of bore 24 (e.g., at least partially withindischarge chamber 53 and/or pump chamber 28) of the pump fluid end 22,such that a discharge valve body of the discharge valve assembly 72moves toward the discharge chamber 53 when the discharge valve assembly72 is in an open configuration and away from the discharge chamber 53when the discharge valve assembly 72 is in a closed configuration. Inaddition, in concentric bore pump fluid end 22 configurations such asFIG. 2A, the discharge valve assembly 72 may be co-axially aligned withthe suction valve assembly 56 (e.g., along central axis 17), and thesuction valve assembly 56 and the discharge valve assembly 72 may becoaxially aligned with the reciprocating element 18 (e.g., along centralaxis 17). In alternative embodiments, such as the T-bore pump fluid end22 embodiment of FIG. 2B, discharge valve assembly 72 can be positionedwithin T-bore 25, at least partially within discharge chamber 53 and/orpump chamber 28, and have a central axis coincident (e.g., coaxial) withcentral axis 27 of T-bore 25.

Further, the suction valve assembly 56 and the discharge valve assembly72 can comprise any suitable mechanism for opening and closing valves.For example, the suction valve assembly 56 and the discharge valveassembly 72 can comprise a suction valve spring and a discharge valvespring, respectively. Additionally, any suitable structure (e.g., valveassembly comprising sealing rings, stems, poppets, etc.) and/orcomponents may be employed suitable means for retaining the componentsof the suction valve assembly 56 and the components of the dischargevalve assembly 72 within the pump fluid end 22 may be employed.

The fluid inlet 38 may be arranged within any suitable portion of thepump fluid end 22 and configured to supply fluid to the pump in anydirection and/or angle. Moreover, the pump fluid end 22 may compriseand/or be coupled to any suitable conduit (e.g., pipe, tubing, or thelike) through which a fluid source may supply fluid to the fluid inlet38. The pump 10 may comprise and/or be coupled to any suitable fluidsource for supplying fluid to the pump via the fluid inlet 38. Inembodiments, the pump 10 may also comprise and/or be coupled to apressure source such as a boost pump (e.g., a suction boost pump)fluidly connected to the pump 10 (e.g., via inlet 38) and operable toincrease or “boost” the pressure of fluid introduced to pump 10 viafluid inlet 38. A boost pump may comprise any suitable type including,but not limited to, a centrifugal pump, a gear pump, a screw pump, aroller pump, a scroll pump, a piston/plunger pump, or any combinationthereof. For instance, the pump 10 may comprise and/or be coupled to aboost pump known to operate efficiently in high-volume operations and/ormay allow the pumping rate therefrom to be adjusted. Skilled artisanswill readily appreciate that the amount of added pressure may dependand/or vary based on factors such as operating conditions, applicationrequirements, etc. In embodiments, the boost pump may have an outletpressure greater than or equal to about 70 psi (0.5 MPa), about 80 psi(0.6 MPa), or about 110 psi (0.8 MPa), providing fluid to the suctionside of pump 10 at about said pressures. Additionally, or alternatively,the boost pump may have a flow rate of greater than or equal to about 80bbl/min (0.21 m³/sec), about 70 BPM bbl/min (0.19 m³/sec), and/or about50 bbl/min (0.13 m³/sec).

As noted hereinabove, the pump 10 may be implemented as a multi-cylinderpump comprising multiple cylindrical reciprocating element bores 24 andcorresponding components. In embodiments, the pump 10 is a triplex pumpin which the pump fluid end 22 comprises three reciprocating assemblies,each reciprocating assembly comprising a suction valve assembly 56, adischarge valve assembly 72, a pump chamber 28, a fluid inlet 38, adischarge outlet 54, and a reciprocating element bore 24 within which acorresponding reciprocating element 18 reciprocates during operation ofthe pump 10 via connection therewith to a (e.g., common) pump power end12. In embodiments, the pump 10 is a quintuplex pump in which the pumpfluid end 22 comprises five reciprocating assemblies. In a non-limitingexample, the pump 10 may be a Q-10™ quintuplex pump or an HT-400™triplex pump, produced by Halliburton Energy Services, Inc.

In embodiments, the pump fluid end 22 may comprise an external manifold(e.g., a suction header) for feeding fluid to the multiple reciprocatingassemblies via any suitable inlet(s). Additionally, or alternatively,the pump fluid end 22 may comprise separate conduits such as hosesfluidly connected to separate inlets for inputting fluid to eachreciprocating assembly. Of course, numerous other variations may besimilarly employed, and therefore, fall within the scope of the presentdisclosure.

Those skilled in the art will understand that the reciprocating elementsof each of the reciprocating assemblies may be operatively connected tothe pump power end 12 of the pump 10 according to any suitable manner.For instance, separate connectors (e.g., cranks arms/connecting rods 21,one or more additional components or mechanical linkages 48, pushrods 9,etc.) associated with the pump power end 12 may be coupled to eachreciprocating element body or tail end 62. The pump 10 may employ acommon crankshaft (e.g., crankshaft 16) or separate crankshafts to drivethe multiple reciprocating elements.

As previously discussed, the fluid inlet(s) 38 may receive a supply offluid from any suitable fluid source, which may be configured to providea constant fluid supply. Additionally, or alternatively, the pressure ofsupplied fluid may be increased by adding pressure (e.g., boostpressure) as described previously. In embodiments, the fluid inlet(s) 38receive a supply of pressurized fluid comprising a pressure ranging fromabout 30 psi (0.2 MPa) to about 300 psi (2.1 MPa).

Additionally, or alternatively, the one or more discharge outlet(s) 54may be fluidly connected to a common collection point such as a sump ordistribution manifold, which may be configured to collect fluids flowingout of the fluid outlet(s) 54, or another cylinder bank and/or one ormore additional pumps.

During pumping, the multiple reciprocating elements 18 will performforward and returns strokes similarly, as described hereinabove. Inembodiments, the multiple reciprocating elements 18 can be angularlyoffset to ensure that no two reciprocating elements are located at thesame position along their respective stroke paths (i.e., the plungersare “out of phase”). For example, the reciprocating elements may beangularly distributed to have a certain offset (e.g., 120 degrees ofseparation in a triplex pump) to minimize undesirable effects that mayresult from multiple reciprocating elements of a single pumpsimultaneously producing pressure pulses. The position of areciprocating element is generally based on the number of degrees a pumpcrankshaft (e.g., crankshaft 16) has rotated from a bottom dead center(BDC) position. The BDC position corresponds to the position of a fullyretracted reciprocating element at zero velocity, e.g., just prior to areciprocating element moving (i.e., in a direction indicated by arrow117 in FIGS. 2A-2B and FIG. 3 ) forward in its cylinder. A top deadcenter position corresponds to the position of a fully extendedreciprocating element at zero velocity, e.g., just prior to areciprocating element moving backward (i.e., in a direction indicated byarrow 116 in FIGS. 2A and 2B) in its cylinder.

As described above, each reciprocating element 18 is operable to draw influid during a suction (backward or return) stroke and discharge fluidduring a discharge (forward) stroke. Skilled artisans will understandthat the multiple reciprocating elements 18 may be angularly offset orphase-shifted to improve fluid intake for each reciprocating element 18.For instance, a phase degree offset (at 360 degrees divided by thenumber of reciprocating elements) may be employed to ensure the multiplereciprocating elements 18 receive fluid and/or a certain quantity offluid at all times of operation. In one implementation, the threereciprocating elements 18 of a triplex pump may be phase-shifted by a120-degree offset. Accordingly, when one reciprocating element 18 is atits maximum forward stroke position, a second reciprocating element 18will be 60 degrees through its discharge stroke from BDC, and a thirdreciprocating element will be 120 degrees through its suction strokefrom top dead center (TDC).

According to this disclosure, and as described further herein, ahorizontal valve assembly comprises a valve guide, a valve body, and avalve stem connecting the valve body to the valve guide.

Referring to FIG. 4 , a horizontal valve assembly 100 with a horizontalcentral axis 17 and that comprises a horizontal guided valve 101disposed within a housing 65 having a valve seat 68 and a valve bodycontact surface 69. The valve seat 68 and valve body contact surface 69may be an insert placed within the housing 65 or may be integral withthe housing 65. The guided valve 101 comprises a valve guide 103 and avalve member that includes a valve body 33 connected to a valve stem 104connecting the valve body 33 to the valve guide 103. A valve spring 31can be present in a bore 66 of the housing 65. The valve body contactsurface 69 and the corresponding contact surface of the valve body areshown as substantially linear, tapering outward to form a frusto-conicalshape. However, any suitable complementary shapes may be used. Forexample, the valve body contact surface 69 and the corresponding contactsurface of the valve body can have a frusto-spherical shape.

The valve 101 operates by the valve member translating in the valveguide to move the valve member between a closed configuration and anopen configuration. In the closed configuration, the valve body 33contacts the valve body contact surface 69 of the valve seat 68 toprevent fluid flow through the valve assembly 100. In the openconfiguration, the valve body 33 does not contact the valve seat 68 toallow fluid flow through the valve assembly 100.

On the suction stroke the valve 101 will move to the open positionrapidly and return rapidly to the closed position on the dischargestroke. The valve 101 will experience very high forces under thepressure sealing and the rapid motion of the valve 101. Given that thereis a clearance between the valve stem 104 and the valve guide 103, thevalve 101 may not be properly aligned and will tilt upon opening asshown in FIG. 4 (e.g., the valve 101 is in the open configuration as thevalve body 33 is not in contact with the valve body contact surface 69).Due to the speed at which a valve 101 returns during pressure sealing,it may not adequately re-center, causing the valve 101 to load at anangle 32 relative to the central axis 17. This undesirable angularloading can cause damage to the horizontal valve assembly 100 such as,for example, causing the valve stem 104 to shear or fatigue and fail.

As depicted in FIG. 5A, illustrates a schematic of the valve assembly ofFIG. 4 , the valve member allows for correction of undesirable angularloading by being moveable during operation such that the orientation ofthe valve body 33 relative to the valve seat 68 is adjustable. To allowthe orientation of the valve body 33 to adjust, the valve body 33 isconnected to the valve stem 104 by a ball joint connection 35 thatallows the valve body 33 to pivot relative to the valve stem 104. Withthe valve member moveable, the valve member can alleviate theundesirable angular loading on the valve assembly 100, thus relievingunwanted stress, decreasing fatigue experienced by, and increasing theoperational life of the valve assembly 100.

FIG. 5B illustrates a schematic of the valve assembly of FIG. 4 havingan obstruction such as a particulate 74 captured between the valve body33 and the valve seat 68 during closing thereof. Should a particulate 74be captured, similar undesirable angular loading could be experienced bythe valve assembly 100. In addition, if the obstruction is large enough,a valve member that is not moveable may not contact the valve seat 68 atall, decreasing the effectiveness of the valve. However, with the valvemember being moveable, the orientation of the valve body 33 adjustsrelative to the valve seat, thus relieving unwanted stress, decreasingfatigue experienced by, and increasing the operational life of the valveassembly 100. Additionally, at least a portion of the valve body 33 maybe adjustable to be able to contact the valve seat 68. While potentiallynot forming a full seal, the moveable valve member is able to block moreflow through the valve assembly 100 than if the valve member were notmoveable.

FIG. 6 illustrates another embodiment of the valve assembly 150,although only the valve member with valve body 33 and valve stem 104 areshown. It is to be appreciated that the other components of the valveassembly 150 include the parts of valve assembly 100. Unlike the valveassembly 100, the valve member in the valve assembly is moveable by thevalve stem 104 being flexible enough to move by bending the valve stem104 in operation. With the connection between the valve body 33 and thevalve stem 104 being rigid, bending the valve stem 104 allows the valvemember to be moveable. With the valve member moveable, the valve membercan alleviate the undesirable angular loading on the valve assembly 150,thus relieving unwanted stress, decreasing fatigue experienced by, andincreasing the operational life of the valve assembly 150.Alternatively, in addition to the valve stem 104 being flexible, theconnection between the valve body 33 and the valve stem 104 may be aball joint as described in FIGS. 5A and 5B, allowing for even moremovement of the valve member.

Also disclosed herein are a method of servicing a wellbore and awellbore servicing system 200 comprising a pump of this disclosure. Anembodiment of a wellbore servicing system 200 and a method of servicinga wellbore via the wellbore servicing system 200 will now be describedwith reference to FIG. 7 , which is a schematic representation of anembodiment of a wellbore servicing system 200, according to embodimentsof this disclosure.

A method of servicing a wellbore 224 according to this disclosurecomprises: fluidly coupling a pump 10 to a source of a wellboreservicing fluid and to the wellbore 224; and communicating wellboreservicing fluid into a formation in fluid communication with thewellbore 224 via the pump 10.

It will be appreciated that the wellbore servicing system 200 disclosedherein can be used for any purpose. In embodiments, the wellboreservicing system 200 may be used to service a wellbore 224 thatpenetrates a subterranean formation by pumping a wellbore servicingfluid into the wellbore and/or subterranean formation. As used herein, a“wellbore servicing fluid” or “servicing fluid” refers to a fluid usedto drill, complete, work over, fracture, repair, or in any way prepare awell bore for the recovery of materials residing in a subterraneanformation penetrated by the well bore. It is to be understood that“subterranean formation” encompasses both areas below exposed earth andareas below earth covered by water such as ocean or fresh water.Examples of servicing fluids suitable for use as the wellbore servicingfluid, the another wellbore servicing fluid, or both include, but arenot limited to, cementitious fluids (e.g., cement slurries), drillingfluids or muds, spacer fluids, fracturing fluids or completion fluids,and gravel pack fluids, remedial fluids, perforating fluids, diverterfluids, sealants, drilling fluids, completion fluids, gelation fluids,polymeric fluids, aqueous fluids, oleaginous fluids, etc.

In embodiments, the wellbore servicing system 200 comprises one or morepumps 10 operable to perform oilfield and/or well servicing operations.Such operations may include, but are not limited to, drillingoperations, fracturing operations, perforating operations, fluid lossoperations, primary cementing operations, secondary or remedialcementing operations, or any combination of operations thereof. Althougha wellbore servicing system is illustrated, skilled artisans willreadily appreciate that the pump 10 disclosed herein may be employed inany suitable operation.

In embodiments, the wellbore servicing system 200 may be a system suchas a fracturing spread for fracturing wells in a hydrocarbon-containingreservoir. In fracturing operations, wellbore servicing fluids, such asparticle laden fluids, are pumped at high-pressure into a wellbore. Theparticle laden fluids may then be introduced into a portion of asubterranean formation at a sufficient pressure and velocity to cut acasing and/or create perforation tunnels and fractures within thesubterranean formation. Proppants, such as grains of sand, are mixedwith the wellbore servicing fluid to keep the fractures open so thathydrocarbons may be produced from the subterranean formation and flowinto the wellbore. Hydraulic fracturing may desirably createhigh-conductivity fluid communication between the wellbore and thesubterranean formation.

The wellbore servicing system 200 comprises a blender 202 that iscoupled to a wellbore services manifold trailer 204 via flowline 206. Asused herein, the term “wellbore services manifold trailer” includes atruck and/or trailer comprising one or more manifolds for receiving,organizing, and/or distributing wellbore servicing fluids duringwellbore servicing operations. In this embodiment, the wellbore servicesmanifold trailer 204 is coupled to six positive displacement pumps(e.g., such as pump 10 that may be mounted to a trailer and transportedto the wellsite via a semi-tractor) via outlet flowlines 208 and inletflowlines 210. In alternative embodiments, however, there may be more orless pumps used in a wellbore servicing operation. Outlet flowlines 208are outlet lines from the wellbore services manifold trailer 204 thatsupply fluid to the pumps 10. Inlet flowlines 210 are inlet lines fromthe pumps 10 that supply fluid to the wellbore services manifold trailer204.

The blender 202 mixes solid and fluid components to achieve awell-blended wellbore servicing fluid. As depicted, sand or proppant212, water 214, and additives 216 are fed into the blender 202 viafeedlines 218, 220, and 222, respectively.

In embodiments, the pump(s) 10 (e.g., pump(s) 10 and/or maintainedpump(s) 10) pressurize the wellbore servicing fluid to a pressuresuitable for delivery into a wellbore 224 or wellhead. For example, thepumps 10 may increase the pressure of the wellbore servicing fluid(e.g., the wellbore servicing fluid and/or the another wellboreservicing fluid) to a pressure of greater than or equal to about 3,000psi (21 MPa), 5,000 psi (34 MPa), 10,000 psi (69 MPa), 20,000 psi (138MPa), 30,000 psi (207 MPa), 40,000 psi (276 MPa), or 50,000 psi (345MPa), or higher.

From the pumps 10, the wellbore servicing fluid may reenter the wellboreservices manifold trailer 204 via inlet flowlines 210 and be combined sothat the wellbore servicing fluid may have a total fluid flow rate thatexits from the wellbore services manifold trailer 204 through flowline226 to the flow connector wellbore 1128 of between about 1 bbl/min(0.003 m³/sec) to about 200 bbl/min (0.53 m³/sec), alternatively frombetween about 50 bbl/min (0.13 m³/sec) to about 150 bbl/min (0.40m³/sec), alternatively about 100 bbl/min (0.26 m³/sec). In embodiments,each of one or more pumps 10 discharge wellbore servicing fluid at afluid flow rate of between about 1 bbl/min (0.003 m³/sec) to about 200bbl/min (0.53 m³/sec), alternatively from between about 50 bbl/min (0.13m³/sec) to about 150 bbl/min (0.40 m³/sec), alternatively about 100bbl/min (0.26 m³/sec). In embodiments, each of one or more pumps 10discharge wellbore servicing fluid at a volumetric flow rate of greaterthan or equal to about 3 bbl/min (0.01 m³/sec), 10 bbl/min (0.03m³/sec), or 20 bbl/min (0.05 m³/sec), or in a range of from about 3bbl/min (0.01 m³/sec) to about 20 bbl/min (0.05 m³/sec), from about 10bbl/min (0.03 m³/sec) to about 20 bbl/min (0.05 m³/sec), or from about 5bbl/min (0.01 m³/sec) to about 20 bbl/min (0.05 m³/sec).

Also disclosed herein are methods for servicing a wellbore (e.g.,wellbore 224). Without limitation, servicing the wellbore may include:positioning the wellbore servicing composition in the wellbore 224(e.g., via one or more pumps 10 as described herein) to isolate thesubterranean formation from a portion of the wellbore; to support aconduit in the wellbore; to plug a void or crack in the conduit; to pluga void or crack in a cement sheath disposed in an annulus of thewellbore; to plug a perforation; to plug an opening between the cementsheath and the conduit; to prevent the loss of aqueous or nonaqueousdrilling fluids into loss circulation zones such as a void, vugularzone, or fracture; to plug a well for abandonment purposes; to diverttreatment fluids; and/or to seal an annulus between the wellbore and anexpandable pipe or pipe string. In other embodiments, the wellboreservicing systems and methods may be employed in well completionoperations such as primary and secondary cementing operation to isolatethe subterranean formation from a different portion of the wellbore.

In embodiments, a wellbore servicing method may comprise transporting apositive displacement pump (e.g., pump 10) to a site for performing aservicing operation. Additionally, or alternatively, one or more pumpsmay be situated on a suitable structural support. Non-limiting examplesof a suitable structural support or supports include a trailer, truck,skid, barge, or combinations thereof. In embodiments, a motor or otherpower source for a pump may be situated on a common structural support.

In embodiments, a wellbore servicing method may comprise providing asource for a wellbore servicing fluid. As described above, the wellboreservicing fluid may comprise any suitable fluid or combinations of fluidas may be appropriate based upon the servicing operation beingperformed. Non-limiting examples of suitable wellbore servicing fluidinclude a fracturing fluid (e.g., a particle laden fluid, as describedherein), a perforating fluid, a cementitious fluid, a sealant, aremedial fluid, a drilling fluid (e.g., mud), a spacer fluid, a gelationfluid, a polymeric fluid, an aqueous fluid, an oleaginous fluid, anemulsion, various other wellbore servicing fluid as will be appreciatedby one of skill in the art with the aid of this disclosure, andcombinations thereof. The wellbore servicing fluid can comprise largeparticles selected from diverting agents, circulation loss materials,drill cuttings, or a combination thereof, for example, wherein the largeparticulates have a diameter of greater than or equal to about 0.07 inch(1.8 mm), 0.12 inch (3.0 mm), or 0.17 inch (4.3 mm). The wellboreservicing fluid may be prepared on-site (e.g., via the operation of oneor more blenders) or, alternatively, transported to the site of theservicing operation.

In embodiments, a wellbore servicing method may comprise fluidlycoupling a pump 10 to the wellbore servicing fluid source. As such,wellbore servicing fluid may be drawn into and emitted from the pump 10.Additionally, or alternatively, a portion of a wellbore servicing fluidplaced in a wellbore 224 may be recycled, i.e., mixed with the waterstream obtained from a water source and treated in fluid treatmentsystem. Furthermore, a wellbore servicing method may comprise conveyingthe wellbore servicing fluid from its source to the wellbore via theoperation of the pump 10 disclosed herein.

Those of ordinary skill in the art will readily appreciate variousbenefits that may be realized by the present disclosure. Slurries withlarge particles create valve sealing issues making them difficult topump. A valve assembly 100 as disclosed herein can be utilized tosuccessfully pump these large particles, while minimizing an amount ofseal lost and damage cause by obstructions such as particles between thevalve body and the valve seat.

Examples of the above embodiments include:

Example 1. A pump assembly, comprising: a power end; a fluid end; and avalve assembly located in the fluid end. The valve assembly comprising:a valve seat; and a valve member comprising a valve body connected to avalve stem and reciprocatable during operation to engage the valve seat,wherein the valve member is moveable during operation such that theorientation of the valve body relative to the valve seat is adjustable.

Example 2. The assembly of Example 1, wherein the valve member istranslatable in a horizontal orientation during operation to seal andunseal against the valve seat.

Example 3. The assembly of Example 1, wherein the valve member ismovable during operation by pivoting the valve body relative to thevalve stem.

Example 4. The assembly of Example 3, wherein the valve body isconnected to the valve stem by a ball joint.

Example 5. The assembly of Example 1, wherein the valve body is rigidlyconnected to the valve stem and the valve member is movable duringoperation by bending the valve stem.

Example 6. The assembly of Example 1, wherein the valve member isengageable with the valve seat to form a seal around the valve seat inmultiple orientations.

Example 7. The assembly of Example 1, wherein the valve member ismoveable during operation in response to an obstruction between thevalve body and the valve seat.

Example 8. The assembly of Example 1, wherein the valve member ismovable during operation by at least one of pivoting the valve bodyrelative to the valve stem or by bending the valve stem.

Example 9. A method of servicing a wellbore, comprising: fluidlycoupling a pump assembly to a source of a wellbore servicing fluid andto the wellbore; and communicating wellbore servicing fluid into thewellbore by operating the pump assembly. Wherein the pump assemblycomprises: a power end; a fluid end; and a valve assembly located in thefluid end and comprising a valve seat and a valve member comprising avalve body connected to a valve stem and reciprocatable during operationto engage the valve seat, wherein the valve member is moveable duringoperation such that the orientation of the valve body relative to thevalve seat is adjustable.

Example 10. The method of Example 9, further comprising translating thevalve member in a horizontal orientation during operation to seal andunseal against the valve seat.

Example 11. The method of Example 9, further comprising wherein thevalve member is movable during operation by pivoting the valve bodyrelative to the valve stem.

Example 12. The assembly of Example 11, wherein the valve body isconnected to the valve stem by a ball joint.

Example 13. The method of Example 9, wherein the valve body is rigidlyconnected to the valve stem and the valve member is movable duringoperation by bending the valve stem.

Example 14. The method of Example 9, wherein the valve member isengageable with the valve seat to form a seal around the valve seat inmultiple orientations.

Example 15. The method of Example 9, further comprising moving the valvemember during operation in response to an obstruction between the valvebody and the valve seat.

Example 16. A valve assembly comprising: a valve seat; and a valvemember comprising a valve body connected to a valve stem andreciprocatable during operation to engage the valve seat, wherein thevalve member is moveable during operation such that the orientation ofthe valve body relative to the valve seat is adjustable.

Example 17. The assembly of Example 16, wherein the valve member ismovable during operation by pivoting the valve body relative to thevalve stem.

Example 18. The assembly of Example 16, wherein the valve body isrigidly connected to the valve stem and the valve member is movableduring operation by bending the valve stem.

Example 19. The assembly of Example 16, wherein the valve member ismoveable during operation in response to an obstruction between thevalve body and the valve seat.

Example 20. The assembly of Example 16, wherein the valve member ismovable during operation by at least one of pivoting the valve bodyrelative to the valve stem or by bending the valve stem.

Certain terms are used throughout the description and claims to refer toparticular features or components. As one skilled in the art willappreciate, different persons may refer to the same feature or componentby different names. This document does not intend to distinguish betweencomponents or features that differ in name but not function.

Unless otherwise indicated, all numbers expressing quantities are to beunderstood as being modified in all instances by the term “about” or“approximately”. Accordingly, unless indicated to the contrary, thenumerical parameters are approximations that may vary depending upon thedesired properties of the present disclosure.

The embodiments disclosed should not be interpreted, or otherwise used,as limiting the scope of the disclosure, including the claims. It is tobe fully recognized that the different teachings of the embodimentsdiscussed may be employed separately or in any suitable combination toproduce desired results. In addition, one skilled in the art willunderstand that the description has broad application, and thediscussion of any embodiment is meant only to be exemplary of thatembodiment, and not intended to suggest that the scope of thedisclosure, including the claims, is limited to that embodiment.

What is claimed is:
 1. A pump assembly, comprising: a power end; a fluidend; and a valve assembly located in the fluid end and comprising: avalve seat; and a valve member comprising a valve body connected to avalve stem and reciprocatable during operation to engage the valve seat,wherein the valve member is moveable during operation such that theorientation of the valve body relative to the valve seat is adjustable.2. The assembly of claim 1, wherein the valve member is translatable ina horizontal orientation during operation to seal and unseal against thevalve seat.
 3. The assembly of claim 1, wherein the valve member ismovable during operation by pivoting the valve body relative to thevalve stem.
 4. The assembly of claim 3, wherein the valve body isconnected to the valve stem by a ball joint.
 5. The assembly of claim 1,wherein the valve body is rigidly connected to the valve stem and thevalve member is movable during operation by bending the valve stem. 6.The assembly of claim 1, wherein the valve member is engageable with thevalve seat to form a seal around the valve seat in multipleorientations.
 7. The assembly of claim 1, wherein the valve member ismoveable during operation in response to an obstruction between thevalve body and the valve seat.
 8. The assembly of claim 1, wherein thevalve member is movable during operation by at least one of pivoting thevalve body relative to the valve stem or by bending the valve stem.
 9. Amethod of servicing a wellbore, comprising: fluidly coupling a pumpassembly to a source of a wellbore servicing fluid and to the wellbore;and communicating wellbore servicing fluid into the wellbore byoperating the pump assembly; wherein the pump assembly comprises: apower end; a fluid end; and a valve assembly located in the fluid endand comprising a valve seat and a valve member comprising a valve bodyconnected to a valve stem and reciprocatable during operation to engagethe valve seat, wherein the valve member is moveable during operationsuch that the orientation of the valve body relative to the valve seatis adjustable.
 10. The method of claim 9, further comprising translatingthe valve member in a horizontal orientation during operation to sealand unseal against the valve seat.
 11. The method of claim 9, furthercomprising wherein the valve member is movable during operation bypivoting the valve body relative to the valve stem.
 12. The assembly ofclaim 11, wherein the valve body is connected to the valve stem by aball joint.
 13. The method of claim 9, wherein the valve body is rigidlyconnected to the valve stem and the valve member is movable duringoperation by bending the valve stem.
 14. The method of claim 9, whereinthe valve member is engageable with the valve seat to form a seal aroundthe valve seat in multiple orientations.
 15. The method of claim 9,further comprising moving the valve member during operation in responseto an obstruction between the valve body and the valve seat.
 16. A valveassembly comprising: a valve seat; and a valve member comprising a valvebody connected to a valve stem and reciprocatable during operation toengage the valve seat, wherein the valve member is moveable duringoperation such that the orientation of the valve body relative to thevalve seat is adjustable.
 17. The assembly of claim 16, wherein thevalve member is movable during operation by pivoting the valve bodyrelative to the valve stem.
 18. The assembly of claim 16, wherein thevalve body is rigidly connected to the valve stem and the valve memberis movable during operation by bending the valve stem.
 19. The assemblyof claim 16, wherein the valve member is moveable during operation inresponse to an obstruction between the valve body and the valve seat.20. The assembly of claim 16, wherein the valve member is movable duringoperation by at least one of pivoting the valve body relative to thevalve stem or by bending the valve stem.